نوع مقاله : مقاله پژوهشی
نویسندگان
دانشکده مهندسی نفت و زمین انرژی،دانشگاه صنعتی امیرکبیر، تهران، ایران
چکیده
کلیدواژهها
موضوعات
عنوان مقاله [English]
نویسندگان [English]
In this study, the effects of migration and swelling of bentonite and kaolinite clay minerals on formation damage during low salinity water flooding under high-temperature conditions were investigated. To simulate a sandstone porous medium, glass micromodels coated with clays and a microfluidic oven set at 70 °C were used to establish reservoir temperature conditions. Five types of formation waters with different ionic compositions of sodium, potassium, and calcium were prepared, and after achieving ionic equilibrium with the environment, distilled water was injected as low salinity water. Moreover, changes in porosity, effective porosity, and permeability were analyzed through image processing over time. The results indicate that the type of ions present in the injected fluid plays a decisive role in the extent of clay swelling and migration. In micromodels coated with bentonite, a combination of potassium and calcium ions effectively controlled clay swelling and migration, while in kaolinite-coated samples, the same combination resulted in the least reduction of reservoir parameters. This study highlights the importance of considering temperature and cation type in predicting formation damage during low salinity water flooding and provides a practical framework for optimizing enhanced oil recovery strategies.
کلیدواژهها [English]
[1]. Bazvand, P., Ahmadpour, K., Niknam, M.R., Nosrat Panah, B., and Daryasafar, A. (2022). A comprehensive review of smart water injection in carbonate and sandstone reservoirs with a special focus at carbonate reservoirs in South of Iran. Journal of Petroleum Research. 32, 124–145. 10.22078/pr.2022.4460.3027.##
[2]. Mwakipunda, G. C., Jia, R., Mgimba, M. M., Ngata, M. R., Mmbuji, A. O., Said, A. A., & Yu, L. (2023). A critical review on low salinity waterflooding for enhanced oil recovery: Experimental studies, simulations, and field applications. Geoenergy Science and Engineering, 227, 211936.doi: 10.1016/j.geoen.2023.211936. ##
[3]. Maghsoudian, A., Izadpanahi, A., Bahmani, Z., Avvali, A. H., & Esfandiarian, A. (2025). Utilizing deterministic smart tools to predict recovery factor performance of smart water injection in carbonate reservoirs. Scientific Reports, 15(1), 537. doi.org/10.1038/s41598-024-84402-3. ##
[4]. Moghadasi, R., Rostami, A., Hemmati-Sarapardeh, A., & Motie, M. (2019). Application of Nanosilica for inhibition of fines migration during low salinity water injection: Experimental study, mechanistic understanding, and model development. Fuel, 242, 846-862. https://www.sciencedirect.com/science/article/pii/S0016236119300547. ##
[5]. Arain, A. H., Negash, B. M., Yekeen, N., Farooqi, A. S., & Alshareef, R. S. (2024). Synergising nanoparticles and low salinity waterflooding for enhanced oil recovery: A state-of-the-art review. Journal of Molecular Liquids, 400, 124495. doi: 10.1016/j.molliq.2024.124495. ##
[6]. Mehdizad, A., Sedaee, B., & Pourafshary, P. (2022). Visual investigation of the effect of clay-induced fluid flow diversion on oil recovery, as a low-salinity water flooding mechanism. Journal of Petroleum Science and Engineering, 209, 109959. https://www.sciencedirect.com/science/article/pii/S0920410521015734. ##
[7]. Yue L, Pu W, Zhao S, Zhang S, Ren F & Xu D. (2020). Insights into mechanism of low salinity water flooding in sandstone reservoir from interfacial features of oil/brine/rock via intermolecular forces. J Mol Liq . 313:113435. https://www.sciencedirect.com/science/article/pii/S016773221936876X. ##
[8]. Villero-Mandon, J., Askar, N., Pourafshary, P., & Riazi, M. (2024). Importance of Fluid/Fluid interactions in enhancing oil recovery by optimizing Low-Salinity waterflooding in sandstones. Energies, 17(13), 3315. doi.org/10.3390/en17133315. ##
[9]. Srivastava, V. R., Sarma, H. K., & Gupta, S. K. (2024). Low-Salinity Waterflooding for EOR in Field A of Western Offshore Basin: A Pilot Study Analysis with Laboratory and Simulation Studies—Early Observations. Energies, 17(9), 2149. doi.org/10.3390/en17092149. ##
[10]. Ligeiro, T. S., Vaz, A., & Chequer, L. (2022). Forecasting the impact of formation damage on relative permeability during low-salinity waterflooding. Journal of Petroleum Science and Engineering, 208, 109500. https://www.sciencedirect.com/science/article/pii/S0920410521011414. ##
[11]. Muneer, R., Pourafshary, P., & Hashmet, M. R. (2023). An integrated modeling approach to predict critical flow rate for fines migration initiation in sandstone reservoirs and water-bearing formations. Journal of Molecular Liquids, 376, 121462. doi: 10.1016/j.molliq.2023.121462. ##
[12]. Ghobadi, H., Riahi, S., & Nakhaee, A. (2021). An investigation and determination of different salinity, ion type and phs effect on fine migration in sandstone reservoirs. Journal Petroleum Research, doi: 10.22078/pr.2021.4524.3039.
[13]. Tong, C.Y., Yang, Y.F., Zhang, Q., Imani, G., Zhang, L., Sun, H., Zhong, J.J., Zhang, K. and Yao, J., ##
[14]. Uetani, T., Takeya, M., & Yogarajah, E. (2026). Exploring the Limit of Low-Salinity Waterflooding in a Carbonate Reservoir with Low Total Acid Number Oil. SPE Journal, 1-16. doi.org/10.2118/221302-MS. ##
[15]. Saghandali, F., Salehi, M.B., Pahlevani, H., Taghikhani, V., Riahi, S., Ebrahimi, M., Saviz, S. and Roomi, A., 2024. Fabrication of a hydrogel reinforced with titanium nanoparticles to reduce fine migration and remediation of formation damage during low-salinity waterflooding. Geoenergy Science and Engineering, 241, p.213173. doi: 10.1016/j.geoen.2024.213173. ##
[16]. Hosseini, A., Almasiyan, P., & Mahani, H. (2024). A triple-layer based surface complexation model for oil-brine interface in low-salinity waterflooding: Effect of sulphate interaction with carboxylic and basic groups, pH and temperature. Journal of Molecular Liquids, 402, 124730. 10.1016/j.molliq.2024.124730. ##
[17]. Musharova, D. A., Mohamed, I. M., & Nasr-El-Din, H. A. (2012, February). Detrimental effect of temperature on fines migration in sandstone formations. In SPE International Conference and Exhibition on Formation Damage Control (pp. SPE-150953). doi.org/10.2118/150953-MS. ##
[18]. Schembre, J. M., Tang, G. Q., & Kovscek, A. R. (2006). Interrelationship of temperature and wettability on the relative permeability of heavy oil in diatomaceous rocks. SPE Reservoir Evaluation & Engineering, 9(03), 239-250. https://doi.org/10.2118/93831-PA. ##
[19]. Ruan K, Wang H, Komine H & Ito D. (2022). Experimental study for temperature effect on swelling pressures during saturation of bentonites. Soils Found.62(6):101245. https://www.sciencedirect.com/science/article/pii/S0038080622001536. ##
[20]. Bag, R., & Rabbani, A. (2017). Effect of temperature on swelling pressure and compressibility characteristics of soil. Applied Clay Science, 136, 1-7. doi.org/10.1016/j.clay.2016.10.043. ##
[21]. Bovard, S., Abbasi, S., Shahrabadi, A., Talebi, A., and Hosseini, S. (2024). A Laboratory Study on the Effect of Low Salinity Water Injection on Recovery Factor in Carbonate Reservoirs. Journal of Petroleum Research. 34, 36–55. 10.22078/pr.2024.5316.3364. ##
[22]. Karami, M., Sedaee, B., & Nakhaee, A. (2023). Microscopic and macroscopic investigation of simultaneous swelling and migration of clays on rock permeability during smart water injection. Journal Petroleum Research doi: 10.22078/pr.2023.5031.3253. ##
[23]. Kashiri, R., Kalantariasl, A., Parsaei, R., Ghaedi, M., and Mahdiyar, H. (2020). Experimental investigation of kaolinite clay role in low salinity water flooding: a micromodel study. Journal of Petroleum Research 30, 72–83. 10.22078/pr.2020.3890.2772.
[24]. Song, W., & Kovscek, A. R. (2015). Functionalization of micromodels with kaolinite for investigation of low salinity oil-recovery processes. Lab on a Chip, 15(16), 3314-3325. doi.org/10.1039/C5LC00544B. ##
[25]. Song, W., & Kovscek, A. R. (2016). Direct visualization of pore-scale fines migration and formation damage during low-salinity waterflooding. Journal of Natural Gas Science and Engineering, 34, 1276-1283. doi: 10.1016/j.jngse.2016.07.055. ##
[26]. Singh, A., Hembram, B. K., Iglauer, S., Keshavarz, A., & Sharma, T. (2025). Pore-scale micromodel experiments for performance evaluation of polymeric nanofluids in CO2 flow through porous media for carbon utilization and storage. Journal of Molecular Liquids, 426, 127358. doi: 10.1016/j.molliq.2025.127358. ##
[27]. Musabbir Rahman, R., Niemur, E., Blois, G., Kazemifar, F., Kim, M., & Li, Y. (2025). A novel microfluidic approach to quantify pore-scale mineral dissolution in porous media. Scientific Reports, 15(1), 6342. ##
[28]. Bear, J. (2013). Dynamics of fluids in porous media. Courier Corporation. https://books.google.com/books?id=lurrmlFGhTEC. ##
[29]. Mortensen, J., Engstrøm, F., & Lind, I. (1998). The relation among porosity, permeability, and specific surface of chalk from the Gorm field, Danish North Sea. SPE Reservoir Evaluation & Engineering, 1(03), 245-251. doi.org/10.2118/31062-PA. ##
[30]. Hussaini, S. R., & Dvorkin, J. (2021). Specific surface area versus porosity from digital images. Journal of Petroleum Science and Engineering, 196, 107773. doi.org/10.1016/j.petrol.2020.107773. ##
[31]. Mehdizad, A., Pourafshary, P., & Sedaee, B. (2022). Visual investigation of simultaneous clay swelling and migration mechanisms and formation damage consequences using micromodels. Journal of Petroleum Science and Engineering, 214, 110561. doi: 10.1016/j.petrol.2022.110561. ##
[32]. Sharifipour, M., Nakhaee, A., & Pourafshary, P. (2019). Model development of permeability impairment due to clay swelling in porous media using micromodels. Journal of Petroleum Science and Engineering, 175, 728-742. doi: 10.1016/j.petrol.2018.12.082. ##
)